WO2016191148A1 - Methods of extracting hydrocarbons from subterranean formations - Google Patents
Methods of extracting hydrocarbons from subterranean formations Download PDFInfo
- Publication number
- WO2016191148A1 WO2016191148A1 PCT/US2016/032841 US2016032841W WO2016191148A1 WO 2016191148 A1 WO2016191148 A1 WO 2016191148A1 US 2016032841 W US2016032841 W US 2016032841W WO 2016191148 A1 WO2016191148 A1 WO 2016191148A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- group
- subterranean formation
- formation
- silicon
- containing compound
- Prior art date
Links
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 247
- 238000000034 method Methods 0.000 title claims abstract description 93
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 77
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 77
- 238000005755 formation reaction Methods 0.000 title description 200
- 239000002210 silicon-based material Substances 0.000 claims abstract description 103
- 239000002245 particle Substances 0.000 claims abstract description 61
- 125000003545 alkoxy group Chemical group 0.000 claims abstract description 20
- XUIMIQQOPSSXEZ-UHFFFAOYSA-N Silicon Chemical group [Si] XUIMIQQOPSSXEZ-UHFFFAOYSA-N 0.000 claims abstract description 18
- 229910052710 silicon Inorganic materials 0.000 claims abstract description 18
- 229910052801 chlorine Chemical group 0.000 claims abstract description 16
- 125000001309 chloro group Chemical group Cl* 0.000 claims abstract description 16
- 125000000217 alkyl group Chemical group 0.000 claims description 56
- 239000000243 solution Substances 0.000 claims description 52
- 239000012530 fluid Substances 0.000 claims description 40
- 230000005660 hydrophilic surface Effects 0.000 claims description 33
- 125000002887 hydroxy group Chemical group [H]O* 0.000 claims description 31
- 239000004215 Carbon black (E152) Substances 0.000 claims description 24
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 16
- 125000005010 perfluoroalkyl group Chemical group 0.000 claims description 15
- 239000000463 material Substances 0.000 claims description 13
- 230000003301 hydrolyzing effect Effects 0.000 claims description 11
- 150000001875 compounds Chemical group 0.000 claims description 9
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 8
- 229920000642 polymer Polymers 0.000 claims description 8
- 238000010794 Cyclic Steam Stimulation Methods 0.000 claims description 6
- 238000010796 Steam-assisted gravity drainage Methods 0.000 claims description 6
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 6
- 125000003178 carboxy group Chemical group [H]OC(*)=O 0.000 claims description 6
- 125000001153 fluoro group Chemical group F* 0.000 claims description 6
- 125000004435 hydrogen atom Chemical group [H]* 0.000 claims description 6
- 238000010795 Steam Flooding Methods 0.000 claims description 5
- 239000012267 brine Substances 0.000 claims description 5
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims description 5
- 239000001569 carbon dioxide Substances 0.000 claims description 4
- 238000005553 drilling Methods 0.000 claims description 4
- 239000006260 foam Substances 0.000 claims description 4
- 239000004094 surface-active agent Substances 0.000 claims description 4
- 229910052731 fluorine Inorganic materials 0.000 claims description 2
- 239000011148 porous material Substances 0.000 description 40
- 230000008569 process Effects 0.000 description 28
- 230000000638 stimulation Effects 0.000 description 22
- 238000011084 recovery Methods 0.000 description 19
- 125000000524 functional group Chemical group 0.000 description 15
- -1 sandstone Substances 0.000 description 15
- 238000006243 chemical reaction Methods 0.000 description 12
- 125000004432 carbon atom Chemical group C* 0.000 description 11
- 238000004519 manufacturing process Methods 0.000 description 8
- 125000003709 fluoroalkyl group Chemical group 0.000 description 7
- 229910052799 carbon Inorganic materials 0.000 description 6
- 239000003921 oil Substances 0.000 description 6
- 230000035699 permeability Effects 0.000 description 6
- 239000007864 aqueous solution Substances 0.000 description 4
- 125000003262 carboxylic acid ester group Chemical group [H]C([H])([*:2])OC(=O)C([H])([H])[*:1] 0.000 description 4
- 239000000460 chlorine Substances 0.000 description 4
- 238000000605 extraction Methods 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 125000005369 trialkoxysilyl group Chemical group 0.000 description 4
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 3
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 3
- 239000002253 acid Substances 0.000 description 3
- 230000003993 interaction Effects 0.000 description 3
- 239000004576 sand Substances 0.000 description 3
- 125000002023 trifluoromethyl group Chemical group FC(F)(F)* 0.000 description 3
- YNQLUTRBYVCPMQ-UHFFFAOYSA-N Ethylbenzene Chemical compound CCC1=CC=CC=C1 YNQLUTRBYVCPMQ-UHFFFAOYSA-N 0.000 description 2
- 235000019738 Limestone Nutrition 0.000 description 2
- IMNFDUFMRHMDMM-UHFFFAOYSA-N N-Heptane Chemical class CCCCCCC IMNFDUFMRHMDMM-UHFFFAOYSA-N 0.000 description 2
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 2
- QAOWNCQODCNURD-UHFFFAOYSA-N Sulfuric acid Chemical compound OS(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 description 2
- 150000001335 aliphatic alkanes Chemical class 0.000 description 2
- 125000003277 amino group Chemical group 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 2
- 239000001273 butane Substances 0.000 description 2
- 125000000484 butyl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 description 2
- 125000002915 carbonyl group Chemical group [*:2]C([*:1])=O 0.000 description 2
- 239000004927 clay Substances 0.000 description 2
- 238000007796 conventional method Methods 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 230000008021 deposition Effects 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 125000001028 difluoromethyl group Chemical group [H]C(F)(F)* 0.000 description 2
- 125000001495 ethyl group Chemical group [H]C([H])([H])C([H])([H])* 0.000 description 2
- 125000003784 fluoroethyl group Chemical group [H]C([H])(F)C([H])([H])* 0.000 description 2
- 125000004216 fluoromethyl group Chemical group [H]C([H])(F)* 0.000 description 2
- 239000001257 hydrogen Substances 0.000 description 2
- 229910052739 hydrogen Inorganic materials 0.000 description 2
- 238000006460 hydrolysis reaction Methods 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 239000006028 limestone Substances 0.000 description 2
- 125000002496 methyl group Chemical group [H]C([H])([H])* 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 2
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 2
- 125000004430 oxygen atom Chemical group O* 0.000 description 2
- 125000006340 pentafluoro ethyl group Chemical group FC(F)(F)C(F)(F)* 0.000 description 2
- 125000001436 propyl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])[H] 0.000 description 2
- 230000004936 stimulating effect Effects 0.000 description 2
- PPDADIYYMSXQJK-UHFFFAOYSA-N trichlorosilicon Chemical group Cl[Si](Cl)Cl PPDADIYYMSXQJK-UHFFFAOYSA-N 0.000 description 2
- QPWHLLKLDQDENW-UHFFFAOYSA-N C(CCCCCCCCC)(=O)OC[Si](Cl)(Cl)Cl Chemical compound C(CCCCCCCCC)(=O)OC[Si](Cl)(Cl)Cl QPWHLLKLDQDENW-UHFFFAOYSA-N 0.000 description 1
- MBFSFLMXGIWMTH-UHFFFAOYSA-N C(CCCCCCCCC)(=O)OC[Si](OC)(OC)OC Chemical compound C(CCCCCCCCC)(=O)OC[Si](OC)(OC)OC MBFSFLMXGIWMTH-UHFFFAOYSA-N 0.000 description 1
- NMKKEWXUKGXLLX-UHFFFAOYSA-N C(CCCCCCCCCCC)(=O)OC[Si](OC)(OC)OC Chemical compound C(CCCCCCCCCCC)(=O)OC[Si](OC)(OC)OC NMKKEWXUKGXLLX-UHFFFAOYSA-N 0.000 description 1
- ZAMOUSCENKQFHK-UHFFFAOYSA-N Chlorine atom Chemical compound [Cl] ZAMOUSCENKQFHK-UHFFFAOYSA-N 0.000 description 1
- SNRUBQQJIBEYMU-UHFFFAOYSA-N Dodecane Natural products CCCCCCCCCCCC SNRUBQQJIBEYMU-UHFFFAOYSA-N 0.000 description 1
- NIIFLEUCTVQZBI-UHFFFAOYSA-N FC(C(=O)OC[Si](Cl)(Cl)Cl)CCCCCCCC Chemical compound FC(C(=O)OC[Si](Cl)(Cl)Cl)CCCCCCCC NIIFLEUCTVQZBI-UHFFFAOYSA-N 0.000 description 1
- PQTMGDNOVYNPPW-UHFFFAOYSA-N FC(C(=O)OC[Si](OC)(OC)OC)CCCCCCCC Chemical compound FC(C(=O)OC[Si](OC)(OC)OC)CCCCCCCC PQTMGDNOVYNPPW-UHFFFAOYSA-N 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 1
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 description 1
- 238000005411 Van der Waals force Methods 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 238000007792 addition Methods 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 150000001299 aldehydes Chemical class 0.000 description 1
- 125000003342 alkenyl group Chemical group 0.000 description 1
- 125000003368 amide group Chemical group 0.000 description 1
- 239000008365 aqueous carrier Substances 0.000 description 1
- 239000010426 asphalt Substances 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 150000003857 carboxamides Chemical class 0.000 description 1
- 150000007942 carboxylates Chemical group 0.000 description 1
- 239000000919 ceramic Substances 0.000 description 1
- 238000006482 condensation reaction Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 125000002704 decyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])* 0.000 description 1
- 238000012217 deletion Methods 0.000 description 1
- 230000037430 deletion Effects 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- MROCJMGDEKINLD-UHFFFAOYSA-N dichlorosilane Chemical compound Cl[SiH2]Cl MROCJMGDEKINLD-UHFFFAOYSA-N 0.000 description 1
- 125000006001 difluoroethyl group Chemical group 0.000 description 1
- 125000003438 dodecyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])* 0.000 description 1
- 150000002148 esters Chemical class 0.000 description 1
- 125000001301 ethoxy group Chemical group [H]C([H])([H])C([H])([H])O* 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 150000004820 halides Chemical group 0.000 description 1
- 150000008282 halocarbons Chemical group 0.000 description 1
- 125000003187 heptyl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 description 1
- 125000004051 hexyl group Chemical group [H]C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])* 0.000 description 1
- 230000007062 hydrolysis Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 150000002576 ketones Chemical class 0.000 description 1
- 239000003949 liquefied natural gas Substances 0.000 description 1
- 239000003915 liquefied petroleum gas Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000012454 non-polar solvent Substances 0.000 description 1
- 125000001400 nonyl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 description 1
- 125000002347 octyl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 description 1
- 125000000962 organic group Chemical group 0.000 description 1
- 125000001147 pentyl group Chemical group C(CCCC)* 0.000 description 1
- 239000012466 permeate Substances 0.000 description 1
- 125000002924 primary amino group Chemical class [H]N([H])* 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 239000001294 propane Substances 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
- 125000000467 secondary amino group Chemical class [H]N([*:1])[*:2] 0.000 description 1
- 239000002356 single layer Substances 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L sulfate group Chemical group S(=O)(=O)([O-])[O-] QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- 125000001273 sulfonato group Chemical group [O-]S(*)(=O)=O 0.000 description 1
- 229910052717 sulfur Inorganic materials 0.000 description 1
- 239000011593 sulfur Substances 0.000 description 1
- 238000010408 sweeping Methods 0.000 description 1
- 150000003512 tertiary amines Chemical class 0.000 description 1
- 239000005052 trichlorosilane Substances 0.000 description 1
- 125000004205 trifluoroethyl group Chemical group [H]C([H])(*)C(F)(F)F 0.000 description 1
- 125000002948 undecyl group Chemical group [H]C([*])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[H] 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/80—Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
- C09K8/805—Coated proppants
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/524—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/80—Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
Definitions
- Embodiments of the disclosure relate generally to methods of extracting hydrocarbons from subterranean formations. More particularly, embodiments of the disclosure relate to methods of reducing asphaltene deposition within a subterranean formation and increasing the recovery of hydrocarbons therefrom.
- hydrocarbons may be recovered (i.e., produced) from one or more subterranean formations through which the wellbore extends.
- natural formation pressures may drive hydrocarbons from the subterranean formation to a production string during what is known in the art as "primary recovery.”
- primary recovery may drive hydrocarbons from the subterranean formation to a production string during what is known in the art as "primary recovery.”
- the formation may be stimulated to enhance the recovery of hydrocarbons therefrom.
- Stimulation methods such as, for example, hydraulic fracturing (i.e., "tracking") may be used to enhance hydrocarbon recovery from the subterranean formation.
- hydraulic fractures are conventionally formed by injecting a fluid (e.g., water) containing additives and including a suspended proppant material (e.g., sand, ceramics, etc.) into a targeted subterranean formation under elevated pressure conditions sufficient to cause the hydrocarbon-bearing formation material to fracture.
- a fluid e.g., water
- a suspended proppant material e.g., sand, ceramics, etc.
- the volume and rate of hydrocarbon recovery from the subterranean formation may depend, at least in part, on the porosity and permeability of the subterranean formation, the size of the fractures formed during hydraulic fracturing, and on fluid properties (e.g., viscosity, composition, etc.) of the hydrocarbons to be produced.
- fluid properties e.g., viscosity, composition, etc.
- hydrocarbons Prior to traveling through the production string and to a surface location above the subterranean formation, hydrocarbons travel through a porous network of the pores of the subterranean formation (e.g., sand, clay, sandstone, limestone, etc.) and through any fractures formed during the hydraulic fracturing.
- asphaltenes within the hydrocarbons may be attracted to formation surfaces of the subterranean formation and to surfaces of proppant particles holding the fractures open, potentially agglomerating and blocking the pores and partially, if not fully, blocking fractures through which the hydrocarbons travel during recovery. Such blocked pores and fractures may decrease the permeability of the subterranean formation and the recovery of the hydrocarbons from the subterranean formation.
- Embodiments disclosed herein include methods of extracting hydrocarbons from a subterranean formation.
- a method of extracting a hydrocarbon material from a subterranean formation comprises introducing a solution comprising a silicon-containing compound into a subterranean formation, the silicon- containing compound comprising a terminal group comprising one of an alkanoate group, a fluoroalkanoate group, and a perfluoroalkanoate group, and one or more of an alkoxy group and a chlorine atom bonded to a silicon atom.
- the method further comprises attaching the silicon-containing compound to one or more of formation surfaces of the subterranean formation and surfaces of proppant particles within fractures of the subterranean formation to form an oleophilic surface on the one or more of the formation surfaces and the surfaces of proppant particles.
- a method of extracting hydrocarbons from a subterranean formation comprises introducing into a subterranean formation a solution comprising a silicon-containing compound having the following structure:
- each R' group comprises one of an alkoxy group, a hydroxyl group, an alkyl group, and a hydrogen atom
- R" comprises one of an alkyl group and a functionalized alkyl group
- R'" comprises one of an alkyl group, a fluorinated alkyl group, and a perfluoroalkyl group.
- the method further comprises extracting hydrocarbons from the subterranean formation.
- a method of extracting a hydrocarbon from a subterranean formation comprises forming an oleophilic surface on one or more of formation surfaces of a subterranean formation and surfaces of proppant particles within the subterranean formation, removing hydrocarbons from the subterranean formation while the oleophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles, hydrolyzing the oleophilic surface and forming a hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles, and removing additional hydrocarbons from the subterranean formation while the hydrophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles.
- FIG. 1A is a simplified cross-sectional view illustrating of a portion of a subterranean formation
- FIG. IB is a simplified cross-sectional view illustrating a pore throat located between adjacent pores of the subterranean formation
- FIG. 1C is a simplified schematic illustrating a cross-sectional view of a pore of the subterranean formation
- FIG. 2 is a simplified cross-sectional view illustrating a pore throat and pores restricted by the presence of asphaltenes
- FIG. 3 is a simplified cross-sectional view illustrating oleophilic formation surfaces of the subterranean formation, in accordance with embodiments of the disclosure
- FIG. 4 is a simplified cross-sectional view illustrating a proppant particle including an oleophilic surface thereon, in accordance with embodiments of the disclosure.
- FIG. 5 is a simplified flow diagram depicting a method of extracting hydrocarbons from a subterranean formation, in accordance with embodiments of the disclosure.
- alkyl group means and includes a group including carbon- hydrogen bonds and may include groups having the general formula C TrustH(2 n+ i ) , wherein n is an integer, such as methyl, ethyl, propyl, butyl, pentyl, hexyl, heptyl, octyl, nonyl, decyl, undecyl, dodecyl, etc., groups.
- Alkyl groups may be straight chained, branched, or ringed structures.
- An alkyl group may include between, for example, about one carbon atom and about thirty carbon atoms (i.e., n may be equal to between about one and about thirty).
- fluoroalkyl group means and includes a group including at least one carbon-hydrogen bond and at least one carbon-fluorine bond.
- a fluoroalkyl group may have the general formula C n H(2n + i- X) F x , wherein n is an integer between about one and about thirty and x is an integer between about one and about sixty.
- n is an integer between about one and about thirty and x is an integer between about one and about sixty.
- perfluoroalkyl group means and includes a group including carbon-fluorine bonds having the general formula C TrustF(2 n+ i ) , wherein n is an integer between about one and about thirty.
- alkanoate means and includes a carboxylic acid ester group bonded to an alkyl group.
- an alkanoate may have the structure shown below:
- R is an alkyl group
- the -COO- group is the carboxylic acid ester group.
- the alkyl group may be functionalized, such as with at least one of a hydroxyl group or other functional group.
- fluoroalkanoate means and includes a carboxylic acid ester group bonded to a fluoroalkyl group and may have the structure above, wherein R is a fluoroalkyl group.
- perfluoroalkanoate means and includes a carboxylic acid ester group bonded to a perfluoroalkyl group and may have the structure shown above, wherein R is a perfluoroalkyl group.
- pore throat means and includes a restricted opening disposed between and interconnecting relatively larger pore volumes within a porous material.
- a solution comprising a silicon-containing compound is introduced into a subterranean formation.
- the silicon-containing compound may be configured to adhere to one or more of formation surfaces of the subterranean formation and surfaces of proppant particles within fractures of the subterranean formation.
- the silicon- containing compound when attached to the formation surfaces and surfaces of proppant particles, may include at least one exposed functional group that reduces an affinity of asphaltenes to such surfaces.
- the at least one exposed functional group may be configured to impart oleophilic properties to surfaces to which the silicon-containing compound is attached.
- the at least one exposed functional group may form an oleophilic surface on formation surfaces (e.g., may cause the formation surfaces to be oil wet).
- Aqueous-based fluids within the pores may be repelled by the oil wet surfaces and may flow out of the pores, increasing an effective hydrocarbon permeability of the formation (e.g., a ilowability of hydrocarbons out of the through pore throats and fractures).
- the silicon-containing compound may subsequently be hydrolyzed to convert the oleophilic surfaces to hydrophilic surfaces.
- Hydrophilic surfaces within the subterranean formation may increase the water wettability (e.g., hydrophilicity) of the subterranean formation and improve the efficiency of aqueous-based enhanced oil recovery stimulation processes such as water flooding, steam assisted gravity drainage, steam flooding, cyclic steam stimulation, polymer flooding, alkaline surfactant polymer flooding, carbon dioxide (C0 2 ) foam flooding, or other enhanced oil recovery stimulation processes.
- An aqueous-based stimulation fluid may more effectively sweep the subterranean formation when the surfaces of the subterranean formation are hydrophilic. Water wet surfaces may repel hydrocarbons from the pores and increase hydrocarbon recovery from the subterranean formation.
- a rate of hydrocarbon recovery from the subterranean formation may be increased by forming oleophilic surfaces within the subterranean formation.
- An effectiveness of an aqueous-based stimulation process may be increased by converting the oleophilic surfaces to hydrophilic surfaces prior to stimulating the subterranean formation with an aqueous-based stimulation fluid.
- the subterranean formation 100 may include a network of pores 120 in the material of the subterranean formation 100 (e.g., grains of formation material 1 10).
- the subterranean formation 100 may be or comprise grains of sand, sandstone, clay, limestone, etc.
- Hydrocarbons may be located within the pores 120.
- hydrocarbons in the pores 120 may travel through fractures formed in the subterranean formation 100, to a production string, and to a surface of the subterranean formation 100.
- the hydrocarbon recovery rate and the pressure required to recover the hydrocarbons may be dependent on, among other factors, the size of the pores 120 and the size of pore throats (designated "D" in FIG. IB).
- box IB in FIG. 1A is shown illustrating a pore throat located between adjacent grains 1 10 of the subterranean formation 100.
- Asphaltenes in such hydrocarbons may undesirably damage wellbore equipment, inhibit the flow of hydrocarbons from the subterranean formation 100, and increase a viscosity of produced hydrocarbons. Asphaltenes may also undesirably deposit on formation surfaces 130 within the pores 120 and pore throats, undesirably decreasing the permeability of the subterranean formation 100.
- the formation surfaces 130 within the pores 120 may include exposed hydroxyl groups 140 thereon.
- Asphaltenes 160 in the hydrocarbons may be attracted to the exposed hydroxyl groups 140 by van der Waals forces, coulombic interactions, ion-dipole interactions, dipole- dipole interactions, and other molecular forces.
- FIG. 2 a portion of a partially restricted subterranean formation 200 is shown.
- Asphaltenes 160 may aggregate at and adhere to the formation surfaces 130 at the exposed hydroxyl groups 140 (FIG. 1C). As the asphaltenes 160 aggregate at the formation surfaces 130 (particularly at or near the pore throats), the pores 120 become narrow and the flow of hydrocarbons through the subterranean formation 200 is substantially restricted.
- a solution including a silicon-containing compound may be introduced into the subterranean formation 100 (FIG. 1A) to reduce deposition of asphaltenes 160 on the formation surfaces 130 within the pores 120.
- the silicon-containing compound may contact the formation surfaces 130 and may be formulated to react with the exposed hydroxyl groups 140 on the formation surfaces 130, reducing the likelihood of asphaltenes 160 adhering to the formation surfaces 130. Reaction of the exposed hydroxyl groups 140 with the silicon-containing compound may attach the silicon-containing compound to the formation surfaces 130.
- the silicon-containing compound may include an oleophilic functional group that is formulated to be exposed when the silicon-containing compound is attached to the formation surfaces 130 within the pores 120.
- the silicon-containing compound may be an ester.
- the silicon-containing compound may include at least one silicon atom bonded to at least one functional group configured to react with the exposed hydroxyl groups 140. Reaction between the at least one functional group and the exposed hydroxyl groups 140 may attach the silicon-containing compound to the formation surfaces 130.
- the silicon atom may also be bonded to another functional group including one or more of a terminal alkyl group, a terminal fluorinated alkyl group, and a terminal perfluoroalkyl group.
- the at least another functional group may exhibit oleophilic properties and a substantially negligible affinity to asphaltenes.
- the at least another functional group may be configured to be exposed when the silicon-containing compound is attached to the formation surface 130.
- a bridge group which may include an alkyl group, may separate the silicon atom from the another functional group.
- the silicon-containing compound may have the following structure:
- R' may include one or more of an alkoxy group (e.g., methoxy (-OCH 3 ), ethoxy (-OC 2 H 5 ), etc.), a hydrogen atom, a hydroxyl group, and an alkyl group;
- R" includes an organic group that may include one or more functional groups (e.g., a hydroxyl group, an amino group, a carbonyl group, a carboxyl group (-COOH), etc.); and R'" includes an alkyl group (e.g., methyl, ethyl, propyl, butyl, etc.), a fluoroalkyl group such as a fluoromethyl group (-CH 2 F), a fluoroethyl group (-C 2 H 4 F, -CH 2 CF 3 , -CH 2 CH 2 CF 2 CF 3 , etc.), a perfluoroalkyl group such as a trifluoromethyl group (-CF 3 ), a pentaflu
- At least one of the R' groups may be configured to react with the exposed hydroxyl groups 140 on the formation surfaces 130. Reaction of the R' group with exposed hydroxyl groups 140 may attach the silicon-containing compound to the formation surfaces 130.
- each of the three R' groups may include the same group. In other embodiments, at least one of the R' groups is different than at least another of the R' groups.
- At least one of the R' groups may include one of an alkyl group and an alkoxy group.
- the silicon atom is bonded to three alkoxy groups and the silicon-containing compound may include a trialkoxy compound, such as, for example, a trimethoxysilyl compound or a triethoxysilyl compound.
- one or two of the R' groups may include one of an alkoxy group and an alkyl group, and the other of the R' groups may include one or more of a hydroxyl group and a hydrogen atom, and the silicon-containing compound may include a mono- or a di- alkoxy compound.
- the R" group may include at least one carbon atom and may include one or more additional functional groups.
- the R" group is a straight chain
- the R'" group may be configured to be exposed after the silicon-containing compound is attached to the formation surface 130.
- the R" group may be configured to impart oleophilic properties to surfaces to which the silicon-containing compound is attached and may be configured to reduce an affinity of asphaltenes to such surfaces.
- the R" group may include an alkyl group, a fluorinated alkyl group, or a perfluoroalkyl group.
- the silicon-containing compound may include an alkanoate.
- the silicon-containing compound may include a fluorinated alkanoate.
- the silicon-containing compound may include a perfluorinated alkanoate.
- the alkyl group, fluorinated alkyl group, and the perfluoroalkyl group may include between about one and about thirty carbon atoms.
- the R'" group may be a linear or a branched structure. A branched R" group may reduce a likelihood of asphaltenes 160 contacting exposed hydroxyl groups 140 on the formation surfaces 130.
- the R" group may include one or more fluorine atoms bonded to one or more of the carbon atoms of the R'" group.
- the R" group include a fluoromethyl group (-CH 2 F), a difluoromethyl group (-CF 2 H), a fluoroethyl group (-CH 2 CH 2 F), a difluoroethyl group (-CH2CHF2), a trifluoroethyl group (-CH 2 CF 3 ), a fluorodecyl group (-CioH 2 oF), a difluorodecyl group (-C10H19F2), a trifluorodecyl group (-C10H18F3), a fluorododecyl group (-C12H24F), a difluorododecyl group (-C12H23F2), a trifluorod
- Each carbon atom of the R'" group may include zero, one, two, or three fluorine atoms. In some embodiments, each carbon atom of the R'" group may include the same or a different number of fluorine atoms. In some embodiments, the fluorine atoms are bonded to the most terminal carbon atom (i.e., the carbon atom most distant from the silicon atom).
- the R'" group may have the general formula -C n F2 n +i, where n is an integer between one and about thirty.
- perfluoroalkyl groups include trifluromethyl (-CF 3 ) and pentafluoroethyl (- C 2 F 5 ).
- the silicon atom may be bonded to at least one chlorine atom.
- the silicon-containing compound may have the following structure:
- each of the R' groups is a chlorine atom and the silicon-containing compound may comprise, for example, a trichlorosilane compound (-S1CI3).
- at least one of the R' groups is a chlorine atom and the other of the R' groups includes one or more of a hydrogen atom, a hydroxyl group, an alkyl group, and an alkoxy group. Silicon-containing compounds including a chlorine atom bonded to the silicon atom may be useful in a subterranean formation without a substantial amount of water.
- the silicon-containing compound may include a compound such as a (trialkoxysilyl)alkyl alkanoate, a (trialkoxysilyl)alkyl fluoroalkanoate, a (trialkoxysilyl)alkyl perfluoroalkanoate, a trichlorosilyl alkyl alkanoate, a trichlorosilyl fluoroalkanoate, and a trichlorosilyl perfluoroalkanoate.
- a compound such as a (trialkoxysilyl)alkyl alkanoate, a (trialkoxysilyl)alkyl fluoroalkanoate, a (trialkoxysilyl)alkyl perfluoroalkanoate, a trichlorosilyl alkyl alkanoate, a trichlorosilyl fluoroalkanoate, and a trichlorosilyl perfluoro
- the silicon-containing compound comprises one or more of (trimethoxysilyl)methyl decanoate ((H3C)3-Si-CH2-COOC9Hi9), (trimethoxylsilyl)methyl dodecanoate ((H3C)3-Si-CH2-COOC n H23), (trimethoxysilyl)methyl fluorodecanoate ((H 3 C) 3 -Si-CH2-COOC 9 F(] -n) H n , wherein n is an integer between one and eighteen), (trimethoxysilyl)methyl perfluorodecanoate ((H3C)3-Si-CH 2 -COOC F2i), (trichlorosilyl)methyl decanoate (Cl 3 -Si-CH 2 -COOC 9 Hi 9 ), (trichlorosilyl)methyl fluorodecanoate (Cl 3 -Si-CH 2 -COOCF(i9-
- the silicon-containing compound may not include a trialkoxysilyl group or a trichlorosilyl group and one or two of the alkoxy groups or chlorine atoms may be replaced with an alkyl group (e.g., the silicon-containing compound may comprise a mono- or di- alkoxysilane or a mono- or di- chlorosilane).
- each silicon-containing compound may be configured to interact with the exposed hydroxyl groups 140 on the formation surfaces 130.
- the silicon-containing compound may attach to the formation surfaces 130 in a silinization reaction or a condensation reaction.
- the silicon-containing compound may be attached to the formation surfaces 130 by reacting a silicon-containing compound including at least one -O-R' group (e.g., an alkoxy group or a peralkoxy group (-0-0-R')) or a silicon-containing compound including at least one R' group including a chlorine atom with an exposed hydroxyl group 140 on the formation surfaces 130.
- the reaction may form the following structure:
- silicon atom is attached (e.g., bonded) to a formation surface 130.
- the silicon atom may also be bonded to an oxygen atom between the silicon-containing compound and an adjacent silicon-containing compound.
- reaction of the silicon-containing compound with exposed hydroxyl groups 140 may form an oleophilic surface 150 on the formation surfaces 130 within the pores 120.
- the oleophilic surface 150 may be a monolayer that substantially surrounds the pores 120 and may include exposed R'" groups.
- the oleophilic surface 150 may substantially reduce a likelihood of asphaltenes from interacting with (e.g., attaching to) the formation surfaces 130 within the pores 120.
- proppant particles may include the silicon-containing compound attached to surfaces thereof.
- a proppant particle 400 may be coated with an oleophilic surface 450.
- the proppant particle 400 may include exposed hydroxyl groups.
- the silicon-containing compound may react with the exposed hydroxyl groups to form the oleophilic surface 450 on the proppant particle 400.
- the silicon-containing compound attaches to the surface of the proppant particles 400 similar to the mechanism by which the silicon-containing compound attaches to formation surfaces 130.
- the silicon-containing compound may include one or more of a -O-R' group (e.g., an alkoxy group) and a R' group comprising a chlorine atom that may react with exposed hydroxyl groups on the surfaces of the proppant particle 400.
- a -O-R' group e.g., an alkoxy group
- R' group comprising a chlorine atom that may react with exposed hydroxyl groups on the surfaces of the proppant particle 400.
- Reaction of the silicon-containing compound with the exposed hydroxyl groups may form the following structure:
- the silicon atom is directly bonded to surfaces of the proppant particle 400.
- the silicon atom may also be bonded to an oxygen atom between the silicon-containing compound and an adjacent silicon-containing compound.
- the R" group may be exposed on the oleophilic surface 450 and may substantially reduce an affinity of asphaltenes to the proppant particle 400.
- the silicon-containing compound may be attached to surfaces of proppant particles 400 prior to introducing the proppant particles 400 into the subterranean formation 100.
- the proppant particles 400 including the silicon-containing compound attached thereto may be introduced into the subterranean formation 100 during fracturing operations.
- the silicon-containing compound may be attached to surfaces of the proppant particles 400 in situ, (e.g., while the proppant particles 400 are within fractures of the subterranean formation 100).
- the subterranean formation 100 may be stimulated with methods such as water flooding, polymer flooding, alkaline surfactant polymer flooding, carbon dioxide (C0 2 ) foam flooding, steam assisted gravity drainage (SAGD), steam flooding, and cyclic steam stimulation (CSS), and related processes in which an aqueous carrier fluid (e.g., water, brine, steam, etc.) is injected into the subterranean formation 100 through injection wells to sweep hydrocarbons contained within the subterranean
- aqueous carrier fluid e.g., water, brine, steam, etc.
- the efficiency of such processes may at least partially depend on the ability of the stimulation fluid to sweep through the pores 120.
- aqueous-based stimulation fluids may not effectively sweep through the pores 120.
- the oleophilic surfaces 150, 450 may be converted to hydrophilic surfaces.
- an exposed -O-R" group of the oleophilic surfaces 150, 450 may be hydrolyzed to convert the oleophilic surface 150, 450 to a hydrophilic surface.
- one or more of an exposed alkanoate group, an exposed fluoroalkanoate group, and an exposed perfluoroalkanoate group of the oleophilic surface 1 0, 450 may be hydrolyzed to convert the oleophilic surfaces 150, 450 to hydrophilic surfaces.
- Hydrolysis of the oleophilic surfaces 150, 450 may include exposing the oleophilic surfaces 150, 450 to an aqueous solution (e.g., water, brine, steam, etc.) in the presence of a base or an acid, such as dilute hydrochloric acid, dilute sulfuric acid, other acids, and combinations thereof.
- aqueous solution e.g., water, brine, steam, etc.
- acid such as dilute hydrochloric acid, dilute sulfuric acid, other acids, and combinations thereof.
- the hydrolysis reaction may proceed according to the following reaction:
- silicon atom of the hydrophilic surface is directly attached to a formation surface 130 or a surface of a proppant particle 400.
- the hydrophilic surfaces may include exposed carboxyl groups (- COOH groups).
- the hydrophilic surfaces may increase the mobility of aqueous solutions within the pores 120 and fractures of the subterranean formation 100, increasing the effectiveness of the aqueous-based stimulation process.
- the silicon-containing compound may be introduced into the subterranean formation 100 to form oleophilic surfaces 150 on the formation surfaces 130 and oleophilic surfaces 450 on surfaces of the proppant particles 400.
- the oleophilic surfaces 150, 450 may promote hydrocarbon recovery during primary production stages. Subsequently, the oleophilic surfaces 150, 450 may be hydrolyzed to form a hydrophilic surface on the formation surfaces 130 and surfaces of the proppant particles 400.
- Aqueous-based stimulation fluids may more effectively sweep the pores 120 when the formation surfaces 130 are hydrophilic, increasing hydrocarbon recovery during the stimulation processes.
- the method 500 may include a solution formation process 502 including forming a solution including a silicon-containing compound and a carrier fluid; a flooding process 504 including introducing the solution into the subterranean formation 100 and contacting one or more of surfaces of proppant particles and formation surfaces of the subterranean formation 100 with the solution to form oleophilic surfaces on one or more of the surfaces of the proppant particles and the formation surfaces; an extraction process 506 including extracting hydrocarbons from the subterranean formation 100; an optional conversion process 508 (shown in broken lines to indicate that the conversion process 508 is optional) including converting the oleophilic surfaces to hydrophilic surfaces; a stimulation process 510 including stimulating the subterranean formation 100; and an additional extraction process 512 including extracting additional hydrocarbons from the subterranean formation 100.
- a solution formation process 502 including forming a solution including a silicon-containing compound and a carrier fluid
- a flooding process 504 including introducing the solution into the subterranean formation
- the solution formation process 502 may include forming a solution including the silicon-containing compound in a carrier fluid.
- the carrier fluid may include a non-aqueous solution and may include, for example, methane, propane, butane, natural gas, liquefied petroleum gas, liquefied natural gas, an alkane such as heptanes and octanes, ethyl benzene, ethanol, methanol, or other suitable organic carrier fluid.
- the silicon-containing compounds may not substantially react with (e.g., crosslink with) the carrier fluid.
- the solution may be formulated to include a concentration of the silicon-containing compound ranging from between about 0.1 volume percent to about 10 volume percent, such as between about 0.1 volume percent and about 0.5 volume percent, between about 0.5 volume percent and about 1.0 volume percent, between about 1.0 volume percent and about 5.0 volume percent, or between about 5.0 volume percent and about 10 volume percent.
- the solution may include more than one type of silicon-containing compound.
- the solution may include a silicon-containing compound wherein the R'" group includes an alkyl group and may also include a silicon-containing compound wherein the R'" group includes one or more of a fluoroalkyl group and a perfluoroalkyl group.
- the solution includes a silicon-containing compound including a chlorine atom and a silicon-containing compound including an alkoxy group.
- the flooding process 504 may include introducing the solution including the silicon-containing compound into the subterranean formation 100 and contacting one or more of the formation surfaces 130 of the subterranean formation 100 and surfaces of proppant particles with the solution.
- the flooding solution may be provided into the subterranean formation 100 through conventional processes. For example, a pressurized stream of the flooding solution may be pumped into an injection well extending to a desired depth in the subterranean formation 100, and may infiltrate (e.g., permeate, diffuse, etc.) into interstitial spaces of the subterranean formation 100.
- exposed hydroxyl groups on formation surfaces 130 within the pores 120 of the subterranean formation 100 and on surfaces of proppant particles may react with at least one R' group of the silicon-containing compound to form the oleophilic monolayers 150, 450.
- the oleophilic surfaces 150, 450 may include exposed R'" groups that may reduce an affinity of asphaltenes to the formation surfaces 130.
- the extraction process 506 may include flowing (e.g., driving, sweeping, forcing, etc.) hydrocarbons from the subterranean formation 100 to the surface.
- the oleophilic surfaces 150, 450 may enhance hydrocarbon recovery during primary recovery.
- some subterranean formations may include water-wet surfaces wherein surfaces of the subterranean formation (e.g., formation surfaces 130) and fractures are hydrophilic.
- the formation may include hydrophilic surfaces formed during drilling, hydraulic fracturing, and completion processes or hydrophilic surfaces naturally present within the subterranean formation 100.
- At least a portion of one or more aqueous-based fluids such as drilling fluids, completion fluids, workover fluids, and hydraulic fracturing fluids may be retained by the subterranean formation (e.g., remain trapped within the pores 120 and fractures) after such processes.
- the trapped fluids may undesirably damage the formation, such as by reducing an effective hydrocarbon permeability and reducing the flowability of the hydrocarbons from the subterranean formation 100.
- some of the trapped fluids create an obstruction in flow paths, such as in the pores 120 and the fractures.
- the oleophilic surfaces 150 e.g., oil wet surfaces
- the optional conversion process 508 may include converting the oleophilic surfaces 150, 450 to hydrophilic surfaces (water wet surfaces).
- the conversion process 508 may be performed after primary recovery has been completed.
- the oleophilic surfaces 150, 450 may be hydrolyzed by contacting the oleophilic surfaces 150, 450 with an aqueous solution including a dilute acid.
- the stimulation process 510 may include introducing a stimulation fluid into the subterranean formation 100 to displace (e.g., drive, sweep, force, etc.) additional
- the stimulation fluid may include an aqueous-based fluid, such as one or more of water, brine, and steam.
- aqueous-based stimulation fluids may be attracted to the hydrophilic surfaces, increasing the efficiency of the stimulation process.
- the hydrophilic surfaces may increase the efficiency of the stimulation process 510 by increasing the water- wettability of the subterranean formation 100 and increasing the mobility of the stimulation fluid within the subterranean formation 100.
- the stimulation fluid may be a non-polar solvent, such as an alkane (e.g., a liquefied butane).
- the additional extraction process 512 may include flowing the additional hydrocarbons (e.g., stimulated hydrocarbons) from within the subterranean formation 100 to the surface.
- the hydrophilic surfaces may increase the hydrocarbons swept and carried to the surface of the subterranean formation 100 by increasing repulsive forces between the hydrocarbons and the hydrophilic surfaces of the formation surfaces 130, the proppant surfaces, and surfaces of the fractures.
- Embodiment 1 A method of recovering a hydrocarbon material from a subterranean formation, the method comprising: introducing a solution comprising a silicon-containing compound into a subterranean formation, the silicon-containing compound comprising: a terminal group comprising one of an alkanoate group, a fluoroalkanoate group, and a perfluoroalkanoate group; and one or more of an alkoxy group and a chlorine atom bonded to a silicon atom; and attaching the silicon-containing compound to one or more of formation surfaces of the subterranean formation and surfaces of proppant particles within fractures of the subterranean formation to form an oleophilic surface on the one or more of the formation surfaces and the surfaces of proppant particles.
- Embodiment 2 The method of Embodiment 1, wherein introducing a solution comprising a silicon-containing compound into a subterranean formation comprises introducing a solution comprising a silicon-containing compound having the following structure:
- R' comprises a chlorine atom
- Embodiment 3 The method of Embodiment 1 or Embodiment 2, wherein introducing a solution comprising a silicon-containing compound into a subterranean formation comprises introducing a solution comprising a silicon-containing compound including at least one fluorine atom into the subterranean formation.
- Embodiment 4 The method of Embodiment 1, wherein introducing a solution comprising a silicon-containing compound into a subterranean formation comprises introducing a solution comprising a silicon-containing compound having the following structure:
- R' groups comprises an alkoxy group
- R" comprises an alkyl group
- R'" comprises one of an alkyl group, a fluorinated alkyl group, and a perfluorinated alkyl group.
- Embodiment 5 The method of Embodiment 1, wherein attaching the
- silicon-containing compound to one or more of formation surfaces of the subterranean formation and surfaces of proppant particles comprises reacting the one or more of an alkoxy group and the chlorine atom with an exposed hydroxyl group of one or more of the formation surfaces and the surfaces of the proppant particles.
- Embodiment 6 The method of any one of Embodiments 1 through 5, further comprising forming a hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles after the silicon-containing compound is attached to one or more of the formation surfaces and the surfaces of the proppant particles.
- Embodiment 7 The method of Embodiment 6, wherein forming a hydrophilic surface comprises hydrolyzing the alkanoate group.
- Embodiment 8 The method of Embodiment 7, further comprising performing one or more of water flooding, polymer flooding, alkaline surfactant polymer flooding, carbon dioxide foam flooding, steam assisted gravity drainage, steam flooding, and cyclic steam stimulation after hydrolyzing the alkanoate group.
- Embodiment 9 A method of extracting hydrocarbons from a subterranean formation, the method comprising: introducing into a subterranean formation a solution comprising a silicon-containing compound having the following structure:
- each R' group comprises one of an alkoxy group, a hydroxyl group, an alkyl group, and a hydrogen atom
- R" comprises one of an alkyl group and a functionalized alkyl group
- R'" comprises one of an alkyl group, a fluorinated alkyl group, and a perfluoroalkyl group
- Embodiment 10 The method of Embodiment 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon- containing compound wherein the R'" group comprises an alkyl group.
- Embodiment 1 1 The method of Embodiment 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon- containing compound wherein the R'" group comprises a fluorinated alkyl group.
- Embodiment 12 The method of Embodiment 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon- containing compound wherein the R'" group comprises a perfluoroalkyl group.
- Embodiment 13 The method of any one of Embodiments 9 through 12, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon-containing compound wherein at least one of the R' groups comprises an alkyl group.
- Embodiment 14 The method of any one of Embodiments 9 through 13, further comprising introducing into the subterranean formation proppant particles suspended within the solution and having the following compound structure on surfaces thereof:
- Embodiment 15 The method of any one of Embodiments 9 through 14, further comprising reacting the silicon-containing compound with exposed hydroxyl groups on formation surfaces of the subterranean formation to form an oleophilic surface comprising exposed R'" groups on the formation surfaces.
- Embodiment 16 The method of Embodiment 15, further comprising hydrolyzing the exposed R'" groups and forming a compound having the following structure:
- Embodiment 17 A method of extracting a hydrocarbon from a subterranean formation, the method comprising: forming an oleophilic surface on one or more of formation surfaces of a subterranean formation and surfaces of proppant particles within the
- subterranean formation removing hydrocarbons from the subterranean formation while the oleophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles; hydrolyzing the oleophilic surface and forming a hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles; and removing additional hydrocarbons from the subterranean formation while the hydrophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles.
- Embodiment 18 The method of Embodiment 17, further comprising removing at least one of a drilling fluid, a completion fluid, a workover fluids, and a hydraulic fracturing fluid from the subterranean formation while the oleophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles.
- Embodiment 19 The method of Embodiment 17 or Embodiment 18, wherein hydrolyzing the oleophilic surface comprises forming an exposed carboxyl group on one or more of the formation surfaces and the surfaces of the proppant particles.
- Embodiment 20 The method of any one of Embodiments 17 through 19, further comprising contacting the hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles with one or more of water, brine, and steam to remove hydrocarbons from the subterranean formation.
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Abstract
A method of extracting hydrocarbons from a subterranean formation comprises introducing a solution comprising a silicon-containing compound into the subterranean formation. The silicon-containing compound may comprise a terminal group comprising one of an alkanoate group, a fluoroalkanoate group, and a perfluoroalkanoate group, and one or more of an alkoxy group and a chlorine atom bonded to the silicon atom. The method comprises attaching the silicon-containing compound to one or more of formation surfaces of the subterranean formation to form an oleophilic surface on the one or more of the formation surfaces and the surfaces of proppant particles.
Description
TITLE
METHODS OF EXTRACTING HYDROCARBONS FROM SUBTERRANEAN FORMATIONS
PRIORITY CLAIM
This application claims the benefit of the filing date of United States Patent
Application Serial No. 14/721,846, filed May 26, 2015, for "Methods of Extracting
Hydrocarbons from Subterranean Formations."
TECHNICAL FIELD
Embodiments of the disclosure relate generally to methods of extracting hydrocarbons from subterranean formations. More particularly, embodiments of the disclosure relate to methods of reducing asphaltene deposition within a subterranean formation and increasing the recovery of hydrocarbons therefrom.
BACKGROUND
Over the production lifetime of a completed wellbore, hydrocarbons may be recovered (i.e., produced) from one or more subterranean formations through which the wellbore extends. For example, natural formation pressures may drive hydrocarbons from the subterranean formation to a production string during what is known in the art as "primary recovery." Subsequently, as production from the subterranean formation decreases, or in some instances during initial completion of a well, the formation may be stimulated to enhance the recovery of hydrocarbons therefrom. Stimulation methods such as, for example, hydraulic fracturing (i.e., "tracking") may be used to enhance hydrocarbon recovery from the subterranean formation. In hydraulic fracturing operations, hydraulic fractures are conventionally formed by injecting a fluid (e.g., water) containing additives and including a suspended proppant material (e.g., sand, ceramics, etc.) into a targeted subterranean formation under elevated pressure conditions sufficient to cause the hydrocarbon-bearing formation material to fracture. The fracturing fluid carries the suspended proppant into the fractures where the proppant remains as pressure is reduced, maintaining open channels in the
The volume and rate of hydrocarbon recovery from the subterranean formation may depend, at least in part, on the porosity and permeability of the subterranean formation, the size of the fractures formed during hydraulic fracturing, and on fluid properties (e.g.,
viscosity, composition, etc.) of the hydrocarbons to be produced. Prior to traveling through the production string and to a surface location above the subterranean formation, hydrocarbons travel through a porous network of the pores of the subterranean formation (e.g., sand, clay, sandstone, limestone, etc.) and through any fractures formed during the hydraulic fracturing. However, asphaltenes within the hydrocarbons may be attracted to formation surfaces of the subterranean formation and to surfaces of proppant particles holding the fractures open, potentially agglomerating and blocking the pores and partially, if not fully, blocking fractures through which the hydrocarbons travel during recovery. Such blocked pores and fractures may decrease the permeability of the subterranean formation and the recovery of the hydrocarbons from the subterranean formation.
DISCLOSURE
Embodiments disclosed herein include methods of extracting hydrocarbons from a subterranean formation. For example, in accordance with one embodiment, a method of extracting a hydrocarbon material from a subterranean formation comprises introducing a solution comprising a silicon-containing compound into a subterranean formation, the silicon- containing compound comprising a terminal group comprising one of an alkanoate group, a fluoroalkanoate group, and a perfluoroalkanoate group, and one or more of an alkoxy group and a chlorine atom bonded to a silicon atom. The method further comprises attaching the silicon-containing compound to one or more of formation surfaces of the subterranean formation and surfaces of proppant particles within fractures of the subterranean formation to form an oleophilic surface on the one or more of the formation surfaces and the surfaces of proppant particles.
In additional embodiments, a method of extracting hydrocarbons from a subterranean formation comprises introducing into a subterranean formation a solution comprising a silicon-containing compound having the following structure:
wherein each R' group comprises one of an alkoxy group, a hydroxyl group, an alkyl group, and a hydrogen atom, R" comprises one of an alkyl group and a functionalized alkyl group,
and R'" comprises one of an alkyl group, a fluorinated alkyl group, and a perfluoroalkyl group. The method further comprises extracting hydrocarbons from the subterranean formation.
In further embodiments, a method of extracting a hydrocarbon from a subterranean formation comprises forming an oleophilic surface on one or more of formation surfaces of a subterranean formation and surfaces of proppant particles within the subterranean formation, removing hydrocarbons from the subterranean formation while the oleophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles, hydrolyzing the oleophilic surface and forming a hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles, and removing additional hydrocarbons from the subterranean formation while the hydrophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles.
BRIEF DESCRIPTION OF DRAWINGS FIG. 1A is a simplified cross-sectional view illustrating of a portion of a subterranean formation;
FIG. IB is a simplified cross-sectional view illustrating a pore throat located between adjacent pores of the subterranean formation;
FIG. 1C is a simplified schematic illustrating a cross-sectional view of a pore of the subterranean formation;
FIG. 2 is a simplified cross-sectional view illustrating a pore throat and pores restricted by the presence of asphaltenes;
FIG. 3 is a simplified cross-sectional view illustrating oleophilic formation surfaces of the subterranean formation, in accordance with embodiments of the disclosure;
FIG. 4 is a simplified cross-sectional view illustrating a proppant particle including an oleophilic surface thereon, in accordance with embodiments of the disclosure; and
FIG. 5 is a simplified flow diagram depicting a method of extracting hydrocarbons from a subterranean formation, in accordance with embodiments of the disclosure.
MODES FOR CARRYING OUT THE INVENTION
The following description provides specific details, such as material types, compositions, material thicknesses, and processing conditions in order to provide a thorough description of embodiments of the disclosure. However, a person of ordinary skill in the art will understand that the embodiments of the disclosure may be practiced without employing these specific details. Indeed, the embodiments of the disclosure may be practiced in
conjunction with conventional techniques employed in the industry. In addition, the description provided below does not form a complete process flow for recovering
hydrocarbons from a hydrocarbon-containing subterranean formation. Only those process acts and structures necessary to understand the embodiments of the disclosure are described in detail below. A person of ordinary skill in the art will understand that some conventional process components (e.g., pumps, controllers, tubular goods, packers, bridge plugs, line filters, valves, temperature detectors, flow detectors, pressure detectors, and the like) and use thereof are inherently disclosed herein and that adding various additional conventional process components and acts would be in accord with the disclosure. Additional acts or materials to treat a subterranean formation and extract a hydrocarbon material from the subterranean formation may be performed by conventional techniques.
As used herein, the term "alkyl group" means and includes a group including carbon- hydrogen bonds and may include groups having the general formula C„H(2n+i), wherein n is an integer, such as methyl, ethyl, propyl, butyl, pentyl, hexyl, heptyl, octyl, nonyl, decyl, undecyl, dodecyl, etc., groups. Alkyl groups may be straight chained, branched, or ringed structures. An alkyl group may include between, for example, about one carbon atom and about thirty carbon atoms (i.e., n may be equal to between about one and about thirty). As used herein, the term "fluoroalkyl group" means and includes a group including at least one carbon-hydrogen bond and at least one carbon-fluorine bond. A fluoroalkyl group may have the general formula CnH(2n+i-X)Fx, wherein n is an integer between about one and about thirty and x is an integer between about one and about sixty. As used herein, the term
"perfluoroalkyl group" means and includes a group including carbon-fluorine bonds having the general formula C„F(2n+i), wherein n is an integer between about one and about thirty.
As used herein, the term "alkanoate" means and includes a carboxylic acid ester group bonded to an alkyl group. For example, an alkanoate may have the structure shown below:
O C O R
wherein R is an alkyl group, and the -COO- group is the carboxylic acid ester group. The alkyl group may be functionalized, such as with at least one of a hydroxyl group or other functional group. As used herein, the term "fluoroalkanoate" means and includes a carboxylic acid ester group bonded to a fluoroalkyl group and may have the structure above, wherein R is a fluoroalkyl group. As used herein, the term "perfluoroalkanoate" means and
includes a carboxylic acid ester group bonded to a perfluoroalkyl group and may have the structure shown above, wherein R is a perfluoroalkyl group.
As used herein, the term "pore throat" means and includes a restricted opening disposed between and interconnecting relatively larger pore volumes within a porous material.
According to embodiments disclosed herein a solution comprising a silicon-containing compound is introduced into a subterranean formation. The silicon-containing compound may be configured to adhere to one or more of formation surfaces of the subterranean formation and surfaces of proppant particles within fractures of the subterranean formation. The silicon- containing compound, when attached to the formation surfaces and surfaces of proppant particles, may include at least one exposed functional group that reduces an affinity of asphaltenes to such surfaces. The at least one exposed functional group may be configured to impart oleophilic properties to surfaces to which the silicon-containing compound is attached. The at least one exposed functional group may form an oleophilic surface on formation surfaces (e.g., may cause the formation surfaces to be oil wet). Aqueous-based fluids within the pores may be repelled by the oil wet surfaces and may flow out of the pores, increasing an effective hydrocarbon permeability of the formation (e.g., a ilowability of hydrocarbons out of the through pore throats and fractures). The silicon-containing compound may subsequently be hydrolyzed to convert the oleophilic surfaces to hydrophilic surfaces. Hydrophilic surfaces within the subterranean formation may increase the water wettability (e.g., hydrophilicity) of the subterranean formation and improve the efficiency of aqueous-based enhanced oil recovery stimulation processes such as water flooding, steam assisted gravity drainage, steam flooding, cyclic steam stimulation, polymer flooding, alkaline surfactant polymer flooding, carbon dioxide (C02) foam flooding, or other enhanced oil recovery stimulation processes. An aqueous-based stimulation fluid may more effectively sweep the subterranean formation when the surfaces of the subterranean formation are hydrophilic. Water wet surfaces may repel hydrocarbons from the pores and increase hydrocarbon recovery from the subterranean formation. Accordingly, a rate of hydrocarbon recovery from the subterranean formation may be increased by forming oleophilic surfaces within the subterranean formation. An effectiveness of an aqueous-based stimulation process may be increased by converting the oleophilic surfaces to hydrophilic surfaces prior to stimulating the subterranean formation with an aqueous-based stimulation fluid.
Referring to FIG. 1 A, a portion of a hydrocarbon-containing subterranean
formation 100 is shown. The subterranean formation 100 may include a network of pores 120 in the material of the subterranean formation 100 (e.g., grains of formation material 1 10). The
subterranean formation 100 may be or comprise grains of sand, sandstone, clay, limestone, etc. Hydrocarbons may be located within the pores 120. During hydrocarbon recovery, hydrocarbons in the pores 120 may travel through fractures formed in the subterranean formation 100, to a production string, and to a surface of the subterranean formation 100. The hydrocarbon recovery rate and the pressure required to recover the hydrocarbons may be dependent on, among other factors, the size of the pores 120 and the size of pore throats (designated "D" in FIG. IB). Referring to FIG. IB, box IB in FIG. 1A is shown illustrating a pore throat located between adjacent grains 1 10 of the subterranean formation 100.
Many producible hydrocarbons (e.g., heavy oils, oil sands, bitumen, etc.) within the subterranean formation 100 may contain asphaltenes. However, asphaltenes in such hydrocarbons may undesirably damage wellbore equipment, inhibit the flow of hydrocarbons from the subterranean formation 100, and increase a viscosity of produced hydrocarbons. Asphaltenes may also undesirably deposit on formation surfaces 130 within the pores 120 and pore throats, undesirably decreasing the permeability of the subterranean formation 100.
Referring to FIG. 1C, a cross-sectional view the formation material 110 is shown. The formation surfaces 130 within the pores 120 may include exposed hydroxyl groups 140 thereon. Asphaltenes 160 in the hydrocarbons may be attracted to the exposed hydroxyl groups 140 by van der Waals forces, coulombic interactions, ion-dipole interactions, dipole- dipole interactions, and other molecular forces. For example, with reference to FIG. 2, a portion of a partially restricted subterranean formation 200 is shown. Asphaltenes 160 may aggregate at and adhere to the formation surfaces 130 at the exposed hydroxyl groups 140 (FIG. 1C). As the asphaltenes 160 aggregate at the formation surfaces 130 (particularly at or near the pore throats), the pores 120 become narrow and the flow of hydrocarbons through the subterranean formation 200 is substantially restricted.
In some embodiments, a solution including a silicon-containing compound may be introduced into the subterranean formation 100 (FIG. 1A) to reduce deposition of asphaltenes 160 on the formation surfaces 130 within the pores 120. The silicon-containing compound may contact the formation surfaces 130 and may be formulated to react with the exposed hydroxyl groups 140 on the formation surfaces 130, reducing the likelihood of asphaltenes 160 adhering to the formation surfaces 130. Reaction of the exposed hydroxyl groups 140 with the silicon-containing compound may attach the silicon-containing compound to the formation surfaces 130. The silicon-containing compound may include an oleophilic functional group that is formulated to be exposed when the silicon-containing compound is attached to the formation surfaces 130 within the pores 120.
The silicon-containing compound may be an ester. The silicon-containing compound may include at least one silicon atom bonded to at least one functional group configured to react with the exposed hydroxyl groups 140. Reaction between the at least one functional group and the exposed hydroxyl groups 140 may attach the silicon-containing compound to the formation surfaces 130. The silicon atom may also be bonded to another functional group including one or more of a terminal alkyl group, a terminal fluorinated alkyl group, and a terminal perfluoroalkyl group. The at least another functional group may exhibit oleophilic properties and a substantially negligible affinity to asphaltenes. The at least another functional group may be configured to be exposed when the silicon-containing compound is attached to the formation surface 130. In some embodiments, a bridge group, which may include an alkyl group, may separate the silicon atom from the another functional group.
In some embodiments, the silicon-containing compound may have the following structure:
wherein R' may include one or more of an alkoxy group (e.g., methoxy (-OCH3), ethoxy (-OC2H5), etc.), a hydrogen atom, a hydroxyl group, and an alkyl group; R" includes an organic group that may include one or more functional groups (e.g., a hydroxyl group, an amino group, a carbonyl group, a carboxyl group (-COOH), etc.); and R'" includes an alkyl group (e.g., methyl, ethyl, propyl, butyl, etc.), a fluoroalkyl group such as a fluoromethyl group (-CH2F), a fluoroethyl group (-C2H4F, -CH2CF3, -CH2CH2CF2CF3, etc.), a perfluoroalkyl group such as a trifluoromethyl group (-CF3), a pentafluoroethyl group (- C2Fs), etc. Each R' group may be the same or may be different.
At least one of the R' groups may be configured to react with the exposed hydroxyl groups 140 on the formation surfaces 130. Reaction of the R' group with exposed hydroxyl groups 140 may attach the silicon-containing compound to the formation surfaces 130. In some embodiments, each of the three R' groups may include the same group. In other embodiments, at least one of the R' groups is different than at least another of the R' groups. At least one of the R' groups may include one of an alkyl group and an alkoxy group. In some
embodiments, the silicon atom is bonded to three alkoxy groups and the silicon-containing compound may include a trialkoxy compound, such as, for example, a trimethoxysilyl compound or a triethoxysilyl compound. In other embodiments, one or two of the R' groups may include one of an alkoxy group and an alkyl group, and the other of the R' groups may include one or more of a hydroxyl group and a hydrogen atom, and the silicon-containing compound may include a mono- or a di- alkoxy compound.
The R" group may include at least one carbon atom and may include one or more additional functional groups. In some embodiments, the R" group is a straight chain
(i.e., linear) alkyl group having between about one and about thirty carbon atoms. In other embodiments, one or more of the carbon atoms of the R" group may include one or more functional groups, such as an alkenyl group (C=C), a hydroxyl group, a carboxyl group, a carbonyl group (a compound including a carbon-oxygen double bond (C=0), such as a ketone, an aldehyde, a carboxylate group (RCOO)), an organohalide group (R-X, wherein R is a hydrocarbon and X is a halide, such as F, CI, Br, or I), an amine group (a primary amine, a secondary amine, a tertiary amine), an amide group (organic amides (-NHCO-), a sulfur-containing group (such as a sulfonate group (RS020 -), a sulfate group (SO4 2 -), etc.), or another functional group.
The R'" group may be configured to be exposed after the silicon-containing compound is attached to the formation surface 130. The R" group may be configured to impart oleophilic properties to surfaces to which the silicon-containing compound is attached and may be configured to reduce an affinity of asphaltenes to such surfaces. The R" group may include an alkyl group, a fluorinated alkyl group, or a perfluoroalkyl group. In embodiments where the R" group is an alkyl group, the silicon-containing compound may include an alkanoate. Where the R" group is a fluorinated alkyl group, the silicon-containing compound may include a fluorinated alkanoate. Where the R'" group is a perfluorinated alkyl group, the silicon-containing compound may include a perfluorinated alkanoate. The alkyl group, fluorinated alkyl group, and the perfluoroalkyl group may include between about one and about thirty carbon atoms. The R'" group may be a linear or a branched structure. A branched R" group may reduce a likelihood of asphaltenes 160 contacting exposed hydroxyl groups 140 on the formation surfaces 130.
In embodiments where the R'" group includes a fluoroalkyl group, the R" group may include one or more fluorine atoms bonded to one or more of the carbon atoms of the R'" group. Non-limiting examples of the R" group include a fluoromethyl group (-CH2F), a difluoromethyl group (-CF2H), a fluoroethyl group (-CH2CH2F), a difluoroethyl group
(-CH2CHF2), a trifluoroethyl group (-CH2CF3), a fluorodecyl group (-CioH2oF), a difluorodecyl group (-C10H19F2), a trifluorodecyl group (-C10H18F3), a fluorododecyl group (-C12H24F), a difluorododecyl group (-C12H23F2), a trifluorododecyl group (-C12H22F3), etc. Each carbon atom of the R'" group may include zero, one, two, or three fluorine atoms. In some embodiments, each carbon atom of the R'" group may include the same or a different number of fluorine atoms. In some embodiments, the fluorine atoms are bonded to the most terminal carbon atom (i.e., the carbon atom most distant from the silicon atom).
Where the R'" group comprises a perfluoroalkyl group, the R'" group may have the general formula -CnF2n+i, where n is an integer between one and about thirty. Non-limiting examples of perfluoroalkyl groups include trifluromethyl (-CF3) and pentafluoroethyl (- C2F5).
In other embodiments, the silicon atom may be bonded to at least one chlorine atom. For example, the silicon-containing compound may have the following structure:
R' O
R' Si R"— C O R'"
R' wherein at least one of the R' groups is chlorine, and R" and R'" are the same as previously described. Thus, in some embodiments, each of the R' groups is a chlorine atom and the silicon-containing compound may comprise, for example, a trichlorosilane compound (-S1CI3). In other embodiments, at least one of the R' groups is a chlorine atom and the other of the R' groups includes one or more of a hydrogen atom, a hydroxyl group, an alkyl group, and an alkoxy group. Silicon-containing compounds including a chlorine atom bonded to the silicon atom may be useful in a subterranean formation without a substantial amount of water.
Accordingly, the silicon-containing compound may include a compound such as a (trialkoxysilyl)alkyl alkanoate, a (trialkoxysilyl)alkyl fluoroalkanoate, a (trialkoxysilyl)alkyl perfluoroalkanoate, a trichlorosilyl alkyl alkanoate, a trichlorosilyl fluoroalkanoate, and a trichlorosilyl perfluoroalkanoate. In some embodiments, the silicon-containing compound comprises one or more of (trimethoxysilyl)methyl decanoate ((H3C)3-Si-CH2-COOC9Hi9), (trimethoxylsilyl)methyl dodecanoate ((H3C)3-Si-CH2-COOCnH23), (trimethoxysilyl)methyl fluorodecanoate ((H3C)3-Si-CH2-COOC9F(] -n)Hn, wherein n is an integer between one and eighteen), (trimethoxysilyl)methyl perfluorodecanoate ((H3C)3-Si-CH2-COOC F2i),
(trichlorosilyl)methyl decanoate (Cl3-Si-CH2-COOC9Hi9), (trichlorosilyl)methyl fluorodecanoate (Cl3-Si-CH2-COOCF(i9-n)Hn, wherein n is an integer between one and eighteen), and (trichlorosilyl)methyl perfluorodecanoate (Cl3-Si-CH2-COOC9F2i). Of course, in some embodiments, the silicon-containing compound may not include a trialkoxysilyl group or a trichlorosilyl group and one or two of the alkoxy groups or chlorine atoms may be replaced with an alkyl group (e.g., the silicon-containing compound may comprise a mono- or di- alkoxysilane or a mono- or di- chlorosilane).
As described above, at least one of the R' groups on each silicon-containing compound may be configured to interact with the exposed hydroxyl groups 140 on the formation surfaces 130. The silicon-containing compound may attach to the formation surfaces 130 in a silinization reaction or a condensation reaction. For example, the silicon-containing compound may be attached to the formation surfaces 130 by reacting a silicon-containing compound including at least one -O-R' group (e.g., an alkoxy group or a peralkoxy group (-0-0-R')) or a silicon-containing compound including at least one R' group including a chlorine atom with an exposed hydroxyl group 140 on the formation surfaces 130. The reaction may form the following structure:
O Si— R"— C O R'" wherein the silicon atom is attached (e.g., bonded) to a formation surface 130. The silicon atom may also be bonded to an oxygen atom between the silicon-containing compound and an adjacent silicon-containing compound.
Referring to FIG. 3, reaction of the silicon-containing compound with exposed hydroxyl groups 140 may form an oleophilic surface 150 on the formation surfaces 130 within the pores 120. The oleophilic surface 150 may be a monolayer that substantially surrounds the pores 120 and may include exposed R'" groups. The oleophilic surface 150 may substantially reduce a likelihood of asphaltenes from interacting with (e.g., attaching to) the formation surfaces 130 within the pores 120.
In some embodiments, proppant particles may include the silicon-containing compound attached to surfaces thereof. Referring to FIG. 4, a proppant particle 400 may be coated with an oleophilic surface 450. For example, the proppant particle 400 may include exposed hydroxyl groups. The silicon-containing compound may react with the exposed hydroxyl groups to form the oleophilic surface 450 on the proppant particle 400. In some
embodiments, the silicon-containing compound attaches to the surface of the proppant particles 400 similar to the mechanism by which the silicon-containing compound attaches to formation surfaces 130. For example, the silicon-containing compound may include one or more of a -O-R' group (e.g., an alkoxy group) and a R' group comprising a chlorine atom that may react with exposed hydroxyl groups on the surfaces of the proppant particle 400.
Reaction of the silicon-containing compound with the exposed hydroxyl groups may form the following structure:
wherein the silicon atom is directly bonded to surfaces of the proppant particle 400. The silicon atom may also be bonded to an oxygen atom between the silicon-containing compound and an adjacent silicon-containing compound. The R" group may be exposed on the oleophilic surface 450 and may substantially reduce an affinity of asphaltenes to the proppant particle 400.
In some embodiments, the silicon-containing compound may be attached to surfaces of proppant particles 400 prior to introducing the proppant particles 400 into the subterranean formation 100. The proppant particles 400 including the silicon-containing compound attached thereto may be introduced into the subterranean formation 100 during fracturing operations. In other embodiments, the silicon-containing compound may be attached to surfaces of the proppant particles 400 in situ, (e.g., while the proppant particles 400 are within fractures of the subterranean formation 100).
In some embodiments, after primary production, it may be desirable to stimulate the subterranean formation 100 to further increase recovery of hydrocarbons within the subterranean formation 100. For example, the subterranean formation 100 may be stimulated with methods such as water flooding, polymer flooding, alkaline surfactant polymer flooding, carbon dioxide (C02) foam flooding, steam assisted gravity drainage (SAGD), steam flooding, and cyclic steam stimulation (CSS), and related processes in which an aqueous carrier fluid (e.g., water, brine, steam, etc.) is injected into the subterranean formation 100 through injection wells to sweep hydrocarbons contained within the subterranean
formation 100 toward the production well. The efficiency of such processes may at least partially depend on the ability of the stimulation fluid to sweep through the pores 120.
However, if the formation surfaces 130 remain oleophilic, aqueous-based stimulation fluids
may not effectively sweep through the pores 120. Thus, it may be desirable to modify the oleophilic surfaces 150, 450 to hydrophilic surfaces prior to, or during, such stimulation procedures.
Accordingly, the oleophilic surfaces 150, 450 may be converted to hydrophilic surfaces. For example, an exposed -O-R" group of the oleophilic surfaces 150, 450 may be hydrolyzed to convert the oleophilic surface 150, 450 to a hydrophilic surface. In some embodiments, one or more of an exposed alkanoate group, an exposed fluoroalkanoate group, and an exposed perfluoroalkanoate group of the oleophilic surface 1 0, 450 may be hydrolyzed to convert the oleophilic surfaces 150, 450 to hydrophilic surfaces. Hydrolysis of the oleophilic surfaces 150, 450 may include exposing the oleophilic surfaces 150, 450 to an aqueous solution (e.g., water, brine, steam, etc.) in the presence of a base or an acid, such as dilute hydrochloric acid, dilute sulfuric acid, other acids, and combinations thereof. The hydrolysis reaction may proceed according to the following reaction:
O o
II
Si R'
-Si R"— C O R'" + H20 c OH
wherein the silicon atom of the hydrophilic surface is directly attached to a formation surface 130 or a surface of a proppant particle 400.
As shown above, the hydrophilic surfaces may include exposed carboxyl groups (- COOH groups). The hydrophilic surfaces may increase the mobility of aqueous solutions within the pores 120 and fractures of the subterranean formation 100, increasing the effectiveness of the aqueous-based stimulation process. Accordingly, the silicon-containing compound may be introduced into the subterranean formation 100 to form oleophilic surfaces 150 on the formation surfaces 130 and oleophilic surfaces 450 on surfaces of the proppant particles 400. The oleophilic surfaces 150, 450 may promote hydrocarbon recovery during primary production stages. Subsequently, the oleophilic surfaces 150, 450 may be hydrolyzed to form a hydrophilic surface on the formation surfaces 130 and surfaces of the proppant particles 400. Aqueous-based stimulation fluids may more effectively sweep the pores 120 when the formation surfaces 130 are hydrophilic, increasing hydrocarbon recovery during the stimulation processes.
Referring to FIG. 5, a simplified flow diagram illustrating a method 500 of obtaining a hydrocarbon material from a subterranean formation 100 in accordance with embodiments of
the disclosure is shown. The method 500 may include a solution formation process 502 including forming a solution including a silicon-containing compound and a carrier fluid; a flooding process 504 including introducing the solution into the subterranean formation 100 and contacting one or more of surfaces of proppant particles and formation surfaces of the subterranean formation 100 with the solution to form oleophilic surfaces on one or more of the surfaces of the proppant particles and the formation surfaces; an extraction process 506 including extracting hydrocarbons from the subterranean formation 100; an optional conversion process 508 (shown in broken lines to indicate that the conversion process 508 is optional) including converting the oleophilic surfaces to hydrophilic surfaces; a stimulation process 510 including stimulating the subterranean formation 100; and an additional extraction process 512 including extracting additional hydrocarbons from the subterranean formation 100.
The solution formation process 502 may include forming a solution including the silicon-containing compound in a carrier fluid. The carrier fluid may include a non-aqueous solution and may include, for example, methane, propane, butane, natural gas, liquefied petroleum gas, liquefied natural gas, an alkane such as heptanes and octanes, ethyl benzene, ethanol, methanol, or other suitable organic carrier fluid. The silicon-containing compounds may not substantially react with (e.g., crosslink with) the carrier fluid.
The solution may be formulated to include a concentration of the silicon-containing compound ranging from between about 0.1 volume percent to about 10 volume percent, such as between about 0.1 volume percent and about 0.5 volume percent, between about 0.5 volume percent and about 1.0 volume percent, between about 1.0 volume percent and about 5.0 volume percent, or between about 5.0 volume percent and about 10 volume percent.
The solution may include more than one type of silicon-containing compound. For example, the solution may include a silicon-containing compound wherein the R'" group includes an alkyl group and may also include a silicon-containing compound wherein the R'" group includes one or more of a fluoroalkyl group and a perfluoroalkyl group. In other embodiments, the solution includes a silicon-containing compound including a chlorine atom and a silicon-containing compound including an alkoxy group.
With continued reference to FIG. 5, the flooding process 504 may include introducing the solution including the silicon-containing compound into the subterranean formation 100 and contacting one or more of the formation surfaces 130 of the subterranean formation 100 and surfaces of proppant particles with the solution. The flooding solution may be provided into the subterranean formation 100 through conventional processes. For example, a
pressurized stream of the flooding solution may be pumped into an injection well extending to a desired depth in the subterranean formation 100, and may infiltrate (e.g., permeate, diffuse, etc.) into interstitial spaces of the subterranean formation 100.
During the flooding process 504, exposed hydroxyl groups on formation surfaces 130 within the pores 120 of the subterranean formation 100 and on surfaces of proppant particles may react with at least one R' group of the silicon-containing compound to form the oleophilic monolayers 150, 450. The oleophilic surfaces 150, 450 may include exposed R'" groups that may reduce an affinity of asphaltenes to the formation surfaces 130.
The extraction process 506 may include flowing (e.g., driving, sweeping, forcing, etc.) hydrocarbons from the subterranean formation 100 to the surface. The oleophilic surfaces 150, 450 may enhance hydrocarbon recovery during primary recovery. For example, some subterranean formations may include water-wet surfaces wherein surfaces of the subterranean formation (e.g., formation surfaces 130) and fractures are hydrophilic. The formation may include hydrophilic surfaces formed during drilling, hydraulic fracturing, and completion processes or hydrophilic surfaces naturally present within the subterranean formation 100. At least a portion of one or more aqueous-based fluids such as drilling fluids, completion fluids, workover fluids, and hydraulic fracturing fluids may be retained by the subterranean formation (e.g., remain trapped within the pores 120 and fractures) after such processes.
However, the trapped fluids may undesirably damage the formation, such as by reducing an effective hydrocarbon permeability and reducing the flowability of the hydrocarbons from the subterranean formation 100. As an example, some of the trapped fluids create an obstruction in flow paths, such as in the pores 120 and the fractures. The oleophilic surfaces 150 (e.g., oil wet surfaces) may increase repulsive forces between the trapped aqueous-based fluids and the oleophilic surfaces 150, displacing the aqueous-based fluids and increasing the effective hydrocarbon permeability in the formation.
With continued reference to FIG. 5, the optional conversion process 508 may include converting the oleophilic surfaces 150, 450 to hydrophilic surfaces (water wet surfaces). In some embodiments, the conversion process 508 may be performed after primary recovery has been completed. The oleophilic surfaces 150, 450 may be hydrolyzed by contacting the oleophilic surfaces 150, 450 with an aqueous solution including a dilute acid.
The stimulation process 510 may include introducing a stimulation fluid into the subterranean formation 100 to displace (e.g., drive, sweep, force, etc.) additional
hydrocarbons from within the subterranean formation 100 to the surface. The stimulation fluid may include an aqueous-based fluid, such as one or more of water, brine, and steam.
Non-limiting examples of stimulation processes include water flooding, steam assisted gravity drainage, steam flooding, and cyclic steam stimulation. In some embodiments, aqueous-based stimulation fluids may be attracted to the hydrophilic surfaces, increasing the efficiency of the stimulation process. The hydrophilic surfaces may increase the efficiency of the stimulation process 510 by increasing the water- wettability of the subterranean formation 100 and increasing the mobility of the stimulation fluid within the subterranean formation 100.
Repulsive forces between the water wet surfaces and any non-aqueous treatment fluids trapped within pores or fractures of the formation may cause the non-aqueous based treatment fluids to flow out of the pores and fractures of the subterranean formation. In other embodiments, where the oleophilic surfaces 150, 450 are not converted to hydrophilic surfaces, the stimulation fluid may be a non-polar solvent, such as an alkane (e.g., a liquefied butane).
The additional extraction process 512 may include flowing the additional hydrocarbons (e.g., stimulated hydrocarbons) from within the subterranean formation 100 to the surface. In embodiments where the oleophilic surfaces 150, 450 are converted to hydrophilic surfaces, the hydrophilic surfaces may increase the hydrocarbons swept and carried to the surface of the subterranean formation 100 by increasing repulsive forces between the hydrocarbons and the hydrophilic surfaces of the formation surfaces 130, the proppant surfaces, and surfaces of the fractures.
Additional non-limiting example embodiments of the disclosure are set forth below.
Embodiment 1 : A method of recovering a hydrocarbon material from a subterranean formation, the method comprising: introducing a solution comprising a silicon-containing compound into a subterranean formation, the silicon-containing compound comprising: a terminal group comprising one of an alkanoate group, a fluoroalkanoate group, and a perfluoroalkanoate group; and one or more of an alkoxy group and a chlorine atom bonded to a silicon atom; and attaching the silicon-containing compound to one or more of formation surfaces of the subterranean formation and surfaces of proppant particles within fractures of the subterranean formation to form an oleophilic surface on the one or more of the formation surfaces and the surfaces of proppant particles.
Embodiment 2: The method of Embodiment 1, wherein introducing a solution comprising a silicon-containing compound into a subterranean formation comprises introducing a solution comprising a silicon-containing compound having the following structure:
R' O R' Si R"— C O R" R'
into the subterranean formation, wherein R' comprises a chlorine atom.
Embodiment 3: The method of Embodiment 1 or Embodiment 2, wherein introducing a solution comprising a silicon-containing compound into a subterranean formation comprises introducing a solution comprising a silicon-containing compound including at least one fluorine atom into the subterranean formation.
Embodiment 4: The method of Embodiment 1, wherein introducing a solution comprising a silicon-containing compound into a subterranean formation comprises introducing a solution comprising a silicon-containing compound having the following structure:
into the subterranean formation, wherein at least one of the R' groups comprises an alkoxy group, R" comprises an alkyl group, and R'" comprises one of an alkyl group, a fluorinated alkyl group, and a perfluorinated alkyl group.
Embodiment 5: The method of Embodiment 1, wherein attaching the
silicon-containing compound to one or more of formation surfaces of the subterranean formation and surfaces of proppant particles comprises reacting the one or more of an alkoxy group and the chlorine atom with an exposed hydroxyl group of one or more of the formation surfaces and the surfaces of the proppant particles.
Embodiment 6: The method of any one of Embodiments 1 through 5, further comprising forming a hydrophilic surface on one or more of the formation surfaces and the
surfaces of the proppant particles after the silicon-containing compound is attached to one or more of the formation surfaces and the surfaces of the proppant particles.
Embodiment 7: The method of Embodiment 6, wherein forming a hydrophilic surface comprises hydrolyzing the alkanoate group.
Embodiment 8: The method of Embodiment 7, further comprising performing one or more of water flooding, polymer flooding, alkaline surfactant polymer flooding, carbon dioxide foam flooding, steam assisted gravity drainage, steam flooding, and cyclic steam stimulation after hydrolyzing the alkanoate group.
Embodiment 9: A method of extracting hydrocarbons from a subterranean formation, the method comprising: introducing into a subterranean formation a solution comprising a silicon-containing compound having the following structure:
wherein each R' group comprises one of an alkoxy group, a hydroxyl group, an alkyl group, and a hydrogen atom, R" comprises one of an alkyl group and a functionalized alkyl group, and R'" comprises one of an alkyl group, a fluorinated alkyl group, and a perfluoroalkyl group; and extracting hydrocarbons from the subterranean formation.
Embodiment 10: The method of Embodiment 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon- containing compound wherein the R'" group comprises an alkyl group.
Embodiment 1 1 : The method of Embodiment 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon- containing compound wherein the R'" group comprises a fluorinated alkyl group.
Embodiment 12: The method of Embodiment 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon- containing compound wherein the R'" group comprises a perfluoroalkyl group.
Embodiment 13: The method of any one of Embodiments 9 through 12, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon-containing compound wherein at least one of the R' groups comprises an alkyl group.
Embodiment 14: The method of any one of Embodiments 9 through 13, further comprising introducing into the subterranean formation proppant particles suspended within the solution and having the following compound structure on surfaces thereof:
wherein the silicon atom of the compound structure is bonded to the proppant particle.
Embodiment 15: The method of any one of Embodiments 9 through 14, further comprising reacting the silicon-containing compound with exposed hydroxyl groups on formation surfaces of the subterranean formation to form an oleophilic surface comprising exposed R'" groups on the formation surfaces.
Embodiment 16: The method of Embodiment 15, further comprising hydrolyzing the exposed R'" groups and forming a compound having the following structure:
O Si R"— C OH
attached to the formation surfaces.
Embodiment 17: A method of extracting a hydrocarbon from a subterranean formation, the method comprising: forming an oleophilic surface on one or more of formation surfaces of a subterranean formation and surfaces of proppant particles within the
subterranean formation; removing hydrocarbons from the subterranean formation while the oleophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles; hydrolyzing the oleophilic surface and forming a hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles; and removing additional hydrocarbons from the subterranean formation while the hydrophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles.
Embodiment 18: The method of Embodiment 17, further comprising removing at least one of a drilling fluid, a completion fluid, a workover fluids, and a hydraulic fracturing fluid from the subterranean formation while the oleophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles.
Embodiment 19: The method of Embodiment 17 or Embodiment 18, wherein hydrolyzing the oleophilic surface comprises forming an exposed carboxyl group on one or more of the formation surfaces and the surfaces of the proppant particles.
Embodiment 20: The method of any one of Embodiments 17 through 19, further comprising contacting the hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles with one or more of water, brine, and steam to remove hydrocarbons from the subterranean formation.
Although the foregoing description contains many specifics, these are not to be construed as limiting the scope of the disclosure, but merely as providing certain
embodiments. Similarly, other embodiments may be devised that do not depart from the scope of the invention. For example, features described herein with reference to one embodiment also may be provided in others of the embodiments described herein. The scope of the invention is, therefore, indicated and limited only by the appended claims and their legal equivalents, rather than by the foregoing description. All additions, deletions, and
modifications to embodiments of the disclosure, as described and illustrated herein, which fall within the meaning and scope of the claims, are encompassed by the invention.
Claims
1. A method of extracting a hydrocarbon material from a subterranean formation, the method comprising:
introducing a solution comprising a silicon-containing compound into a subterranean
formation, the silicon-containing compound comprising:
a terminal group comprising one of an alkanoate group, a fluoroalkanoate group, and a perfluoroalkanoate group; and
one or more of an alkoxy group and a chlorine atom bonded to a silicon atom; and attaching the silicon-containing compound to one or more of formation surfaces of the
subterranean formation and surfaces of proppant particles within fractures of the subterranean formation to form an oleophilic surface on the one or more of the formation surfaces and the surfaces of proppant particles.
2. The method of claim 1, wherein introducing a solution comprising a silicon-containing compound into a subterranean formation comprises introducing a solution comprising a silicon-containing compound having the following structure:
R' O
R Si R"— C O R'"
R
into the subterranean formation, wherein R' comprises a chlorine atom.
3. The method of claim 1, wherein introducing a solution comprising a silicon-containing compound into a subterranean formation comprises introducing a solution comprising a silicon-containing compound including at least one fluorine atom into the subterranean fonnation.
4. The method of claim 1, wherein introducing a solution comprising a silicon-containing compound into a subterranean formation comprises introducing a solution comprising a silicon-containing compound having the following structure:
into the subterranean formation, wherein at least one of the R' groups comprises an alkoxy group, R" comprises an alkyl group, and R'" comprises one of an alkyl group, a fluorinated alkyl group, and a perfluorinated alkyl group.
5. The method of claim 1, wherein attaching the silicon-containing compound to one or more of formation surfaces of the subterranean formation and surfaces of proppant particles comprises reacting the one or more of an alkoxy group and the chlorine atom with an exposed hydroxyl group of one or more of the formation surfaces and the surfaces of the proppant particles.
6. The method of claim 1, further comprising forming a hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles after the silicon-containing compound is attached to one or more of the formation surfaces and the surfaces of the proppant particles.
7. The method of claim 6, wherein forming a hydrophilic surface comprises hydrolyzing the alkanoate group.
8. The method of claim 7, further comprising performing one or more of water flooding, polymer flooding, alkaline surfactant polymer flooding, carbon dioxide foam flooding, steam assisted gravity drainage, steam flooding, and cyclic steam stimulation after hydrolyzing the alkanoate group.
9. A method of extracting hydrocarbons from a subterranean formation, the method comprising:
introducing into a subterranean formation a solution comprising a silicon-containing compound having the following structure:
wherein each R' group comprises one of an alkoxy group, a hydroxyl group, an alkyl group, and a hydrogen atom, R" comprises one of an alkyl group and a functionalized alkyl group, and R'" comprises one of an alkyl group, a fluorinated alkyl group, and a perfluoroalkyl group; and
extracting hydrocarbons from the subterranean formation.
10. The method of claim 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon-containing compound wherein the R'" group comprises an alkyl group.
1 1. The method of claim 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon-containing compound wherein the R'" group comprises a fluorinated alkyl group.
12. The method of claim 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon-containing compound wherein the R'" group comprises a perfluoroalkyl group.
13. The method of claim 9, wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon-containing compound wherein at least one of the R' groups comprises an alkyl group.
14. The method of claim 9, further comprising introducing into the subterranean formation proppant particles suspended within the solution and having the following compound structure on surfaces thereof:
O
-Si— R"— C- -o- -R' wherein the silicon atom of the compound structure is bonded to the proppant particle.
15. The method of claim 9, further comprising reacting the silicon-containing compound with exposed hydroxyl groups on formation surfaces of the subterranean formation to form an oleophilic surface comprising exposed R'" groups on the formation surfaces.
16. The method of claim 15, further comprising hydrolyzing the exposed R' groups and forming a compound having the following structure:
I O
Si R"— C OH
attached to the formation surfaces.
17. A method of extracting a hydrocarbon from a subterranean formation, the method comprising:
forming an oleophilic surface on one or more of formation surfaces of a subterranean
formation and surfaces of proppant particles within the subterranean formation; removing hydrocarbons from the subterranean formation while the oleophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles; hydrolyzing the oleophilic surface and forming a hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles; and
removing additional hydrocarbons from the subterranean formation while the hydrophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles.
18. The method of claim 17, further comprising removing at least one of a drilling fluid, a completion fluid, a workover fluid, and a hydraulic fracturing fluid from the subterranean formation while the oleophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles.
19. The method of claim 17, wherein hydrolyzing the oleophilic surface comprises forming an exposed carboxyl group on one or more of the formation surfaces and the surfaces of the proppant particles.
20. The method of claim 17, further comprising contacting the hydrophilic surface on one or more of the formation surfaces and the surfaces of the proppant particles with one or more of water, brine, and steam to remove hydrocarbons from the subterranean formation.
Priority Applications (1)
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CA2990771A CA2990771A1 (en) | 2015-05-26 | 2016-05-17 | Methods of extracting hydrocarbons from subterranean formations |
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US14/721,846 | 2015-05-26 | ||
US14/721,846 US9816026B2 (en) | 2015-05-26 | 2015-05-26 | Methods of extracting hydrocarbons from subterranean formations |
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Also Published As
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US10259992B2 (en) | 2019-04-16 |
US20160348488A1 (en) | 2016-12-01 |
US9816026B2 (en) | 2017-11-14 |
CA2990771A1 (en) | 2016-12-01 |
US20180044580A1 (en) | 2018-02-15 |
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